EP2963284B1 - Procédés et systèmes pour faire fonctionner un système de turbine éolienne - Google Patents

Procédés et systèmes pour faire fonctionner un système de turbine éolienne Download PDF

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Publication number
EP2963284B1
EP2963284B1 EP15171870.7A EP15171870A EP2963284B1 EP 2963284 B1 EP2963284 B1 EP 2963284B1 EP 15171870 A EP15171870 A EP 15171870A EP 2963284 B1 EP2963284 B1 EP 2963284B1
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EP
European Patent Office
Prior art keywords
rotor
over
speed
wind turbine
time
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EP15171870.7A
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German (de)
English (en)
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EP2963284A1 (fr
Inventor
Ameet Shridhar Deshpande
Pranav Agarwal
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General Electric Co
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General Electric Co
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    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03D—WIND MOTORS
    • F03D7/00—Controlling wind motors 
    • F03D7/02—Controlling wind motors  the wind motors having rotation axis substantially parallel to the air flow entering the rotor
    • F03D7/04—Automatic control; Regulation
    • F03D7/042—Automatic control; Regulation by means of an electrical or electronic controller
    • F03D7/043—Automatic control; Regulation by means of an electrical or electronic controller characterised by the type of control logic
    • F03D7/045—Automatic control; Regulation by means of an electrical or electronic controller characterised by the type of control logic with model-based controls
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F03—MACHINES OR ENGINES FOR LIQUIDS; WIND, SPRING, OR WEIGHT MOTORS; PRODUCING MECHANICAL POWER OR A REACTIVE PROPULSIVE THRUST, NOT OTHERWISE PROVIDED FOR
    • F03D—WIND MOTORS
    • F03D7/00—Controlling wind motors 
    • F03D7/02—Controlling wind motors  the wind motors having rotation axis substantially parallel to the air flow entering the rotor
    • F03D7/022—Adjusting aerodynamic properties of the blades
    • F03D7/0224—Adjusting blade pitch
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2260/00—Function
    • F05B2260/70—Adjusting of angle of incidence or attack of rotating blades
    • F05B2260/74—Adjusting of angle of incidence or attack of rotating blades by turning around an axis perpendicular the rotor centre line
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2260/00—Function
    • F05B2260/82—Forecasts
    • F05B2260/821—Parameter estimation or prediction
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2270/00—Control
    • F05B2270/10—Purpose of the control system
    • F05B2270/101—Purpose of the control system to control rotational speed (n)
    • F05B2270/1011—Purpose of the control system to control rotational speed (n) to prevent overspeed
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2270/00—Control
    • F05B2270/30—Control parameters, e.g. input parameters
    • F05B2270/309—Rate of change of parameters
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2270/00—Control
    • F05B2270/30—Control parameters, e.g. input parameters
    • F05B2270/327—Rotor or generator speeds
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F05—INDEXING SCHEMES RELATING TO ENGINES OR PUMPS IN VARIOUS SUBCLASSES OF CLASSES F01-F04
    • F05B—INDEXING SCHEME RELATING TO WIND, SPRING, WEIGHT, INERTIA OR LIKE MOTORS, TO MACHINES OR ENGINES FOR LIQUIDS COVERED BY SUBCLASSES F03B, F03D AND F03G
    • F05B2270/00—Control
    • F05B2270/40—Type of control system
    • F05B2270/404—Type of control system active, predictive, or anticipative
    • Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
    • Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
    • Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
    • Y02E10/00—Energy generation through renewable energy sources
    • Y02E10/70—Wind energy
    • Y02E10/72—Wind turbines with rotation axis in wind direction

Definitions

  • Wind turbines are increasingly gaining importance as renewable sources of energy generation, and wind turbine technology has increasingly been applied to large-scale power generation applications. Maximizing energy output while minimizing loads of the wind turbines in varied wind conditions is a challenge that exists in harnessing wind energy.
  • a wind turbine typically includes at least one rotor mounted on a housing or nacelle which is positioned on top of a truss or a tubular tower.
  • Certain wind turbines designed to provide electrical power to utility grids, include large rotors with diameters extending 80 or more meters. Each of these rotors includes one or more blades. The rotor blades transform the wind energy into rotational energy which drives a generator operationally coupled to the rotor.
  • the generator may be coupled to the rotor either directly or via a gearbox.
  • the gearbox is used for stepping up the inherently low rotational speed of the rotor so that the generator may efficiently convert the rotational energy into electrical power.
  • the rotor of a wind turbine may rotate faster than under normal conditions. If unchecked, the rotor could continue to accelerate until internal forces and resonances cause instability - a phenomenon known as over speeding.
  • modem wind turbines have mechanisms, such as pitch angle controls, for controlling rotor speeds.
  • at least some known wind turbines also include braking systems to satisfy safety requirements.
  • some known wind turbines may include a disk brake to facilitate stopping the wind turbine rotor against full wind torque and/or stored energy sources such as hydraulic accumulators or capacitors to enable braking during power failure. See, for example, Pao LY et al "Control of wind turbines", IEEE Control systems, IEEE, USA, Vol. 31, no. 2, 1 April 2011, PP. 44-62, XP 011372740, ISSN 1066-033X .
  • control system or “controller” may include either a single component or a plurality of components, which are either active and/or passive and are connected or otherwise coupled together to provide the described function or functions.
  • Fig. 1 is an exemplary representation of a wind turbine 10.
  • the wind turbine 10 illustrated for purposes of example is a horizontal-axis electrical power generating wind turbine, in some embodiments, the wind turbine 10 may comprise a vertical-axis configuration and/or a wind mill type wind turbine (not shown).
  • the wind turbine 10 may be coupled to a power grid (not shown) for receiving electrical power therefrom to drive operation of the wind turbine 10 and/or its associated components and/or for supplying electrical power generated by wind turbine 10 thereto.
  • a plurality of wind turbines 10 may be grouped together such that the group may be referred to as a "wind farm.”
  • the wind turbine 10 includes a tower 14, a body 16 (sometimes referred to as a "nacelle") and a rotor 18 coupled to the body 16 for rotation with respect to the body 16 about an axis of rotation 20.
  • the rotor 18 includes a hub 22 and one or more blades 24 extending radially outwardly from the hub 22 for converting wind energy into rotational energy.
  • the rotor 18 is described and illustrated herein as having three blades 24, the rotor 18 may have any number of blades 24. The length of the blades 24 may vary depending on the application.
  • the rotor 18 generally faces upwind to harness the wind energy.
  • the rotor 18 faces downwind to harness the wind energy.
  • the rotor 18 may not face exactly upwind or downwind, but may be inclined generally at any angle (which may be variable) with respect to a direction of the wind to harness energy therefrom.
  • the rotor 18 may include the blades 24 of any shape, type, and configuration.
  • the rotor 18 may include a ducted rotor, a darrieus wind turbine rotor, a savonious wind turbine rotor, a traditional windmill rotor, or the like.
  • the traditional windmill rotor for example may be for pumping water, such as, but not limited to, four-bladed rotors having wooden shutters and/or fabric sails.
  • the wind turbine 10 further includes one or more sensors 12 coupled to one or more components of the wind turbine 10 and/or the power grid, for measuring one or more parameters of such components.
  • the sensors 12 may include, but are not limited to, sensors configured to measure current rotor speed, current rotor acceleration, current pitch angles of one or more of the blades 24, displacements, yaw, moments, strain, stress, twist, damage, failure, rotor torque, an anomaly in the power grid, generator speed, and/or an anomaly of power supplied to any component of the wind turbine 10.
  • the wind turbine 10 further includes one or more control systems 28 coupled to the sensors 12 and at least some of the components of wind turbine 10 for generally controlling operation of wind turbine 10.
  • the control system 28 is disposed within the wind turbine 10.
  • the control system 28 may be remote from the wind turbine 10 and/or other components of the wind turbine 10.
  • the control system 28 may be used for overall system monitoring and control including, for example, blade pitch and speed regulation, high-speed shaft and yaw brake applications, yaw and pump motor applications, and/or fault monitoring.
  • Alternative distributed or centralized control architectures may be used in some embodiments.
  • Fig. 2 is a partial-cut away perspective view of a portion of the wind turbine 10 shown in Fig. 1 .
  • the wind turbine 10 includes one or more torque control devices.
  • the torque control devices may include a converter, for example, an electrical generator, a battery storage device, and/or a shunt resistor load.
  • the torque control device comprises an electrical generator 26 coupled to the rotor 18.
  • the electrical generator 26 is coupled to the rotor 18 via a gearbox (not shown).
  • the electrical generator 26 may be any suitable type of electrical generator, such as, but not limited to, a wound rotor induction generator.
  • the wind turbine 10 may include a brake 30 such as, for example, a hydraulic parking brake, an electromechanical brake, a centrifugal brake, an Eddie-current brake (retarder), or a magnetic brake, for braking rotation of the rotor 18 to, for example slow rotation of the rotor 18, brake the rotor 18 against full wind torque, and/or reduce the generation of electrical power from the electrical generator 26.
  • a brake 30 such as, for example, a hydraulic parking brake, an electromechanical brake, a centrifugal brake, an Eddie-current brake (retarder), or a magnetic brake, for braking rotation of the rotor 18 to, for example slow rotation of the rotor 18, brake the rotor 18 against full wind torque, and/or reduce the generation of electrical power from the electrical generator 26.
  • the wind turbine 10 may further include a pitch control device, such as, a variable blade pitch system 32 for selectively controlling a pitch angle of the blades 24.
  • a pitch control device such as, a variable blade pitch system 32 for selectively controlling a pitch angle of the blades 24.
  • the pitch angles of the blades 24 are individually controlled by the variable blade pitch system 32.
  • the variable blade pitch system 32 may include one or more actuators 34 coupled to the hub 22 and the blades 24 for changing the pitch angle of the blades 24.
  • the actuators 34 may include but are not limited to, electrical motors, hydraulic cylinders, springs, and/or servo-mechanisms and may be driven by any suitable means, such as, but not limited to, hydraulic fluid, electrical power, electro-chemical power, and/or mechanical power.
  • the actuators 34 may be driven by energy extracted from rotational inertia of the rotor 18, and/or a stored energy source (not shown) that supplies power to components of the wind turbine 10 during a grid anomaly in the power grid coupled to wind turbine 10.
  • the wind turbine 10 further includes the sensors 12 and the control system 28.
  • the control system 28 for example, may be a processing subsystem, a processor, a microprocessor, an embedded chip, or the like.
  • the control system 28 is operationally coupled to the brake 30 and the variable pitch controller 32.
  • the sensors 12 are positioned with respect to one or more components of the wind turbine 10 and/or the power grid, for measuring one or more parameters of such components.
  • the exemplary sensors 12 are illustrated herein as coupled to various components of wind turbine 10, including the tower 14, the plurality of blades 24, and the hub 22, the sensors 12 illustrated herein are not limited to the components each sensor is shown as coupled to, nor the location shown on such components. Rather, the sensors 12 may be coupled to any component of the wind turbine 10 and/or the power grid at any location thereof for measuring any parameter thereof.
  • Fig. 3 is a flow chart illustrating a method 300 to operate the wind turbine 10 referred to in Fig. 1 and Fig. 2 , in accordance with a more specific aspect of this embodiment.
  • Reference numeral 302 is representative of current rotor speed
  • reference numeral 304 is representative of current rotor acceleration.
  • the current rotor speed 302 and the current rotor acceleration 304 may be generated by the sensors 12 or may be determined based upon information sensed by the sensors 12.
  • a prediction of an over-speeding time T of the occurrence of the over-speed rotor event may be determined based at least in part on the current rotor speed 302, current rotor acceleration 304, and an available counter-torque margin. More specifically, if there is sufficient available counter-torque margin to compensate for a potential over-speed event, that would otherwise be expected based on the current rotor speed and current rotor acceleration, the over-speeding time T is not predicted as such compensation is expected to prevent the over-speed event.
  • T is the over-speeding time
  • J r is rotor inertia
  • M z is aerodynamic torque
  • ⁇ M Z / ⁇ is an aerodynamic sensitivity and a change in aerodynamic torque with respect to a change in rotor speed
  • ⁇ max is maximum allowable rotor speed of the rotor 18
  • ⁇ 0 is current rotor speed
  • ⁇ 0 current rotor acceleration
  • Q g max is the maximum available counter-torque
  • Q g 0 is current counter-torque.
  • the over-speeding time T may be predicted without usage of wind speed data or wind speed related estimations and, when doing so, does not contain errors that exist due to lags in wind speed measurements or estimation. Equation (2) is derived assuming that rotor speed at the over-speeding time T is substantially equal to the maximum allowable rotor speed ⁇ max .
  • pitch commands are generated to avoid the over-speed rotor event.
  • the pitch commands are generated for the pitch angles of the blades 24.
  • the pitch commands are generated based at least in part on one or more analytical transfer functions that define the dynamics of the wind turbine 10, and one or more aerodynamic sensitivities.
  • ⁇ M z ⁇ ⁇ is change in the aerodynamic torque with respect to unit change in the pitch angles
  • ⁇ v is change in speed of wind
  • ⁇ M z ⁇ ⁇ is change in aerodynamic torque with respect to unit change in rotor speed
  • ⁇ M z ⁇ v is change in aerodynamic torque with respect to unit change in speed of wind.
  • equation (3) also is a first order differential equation governing rotor speed of the rotor 18.
  • the pitch commands are generated based upon at least in part on determination of a minimum pitch angle alteration needed to avoid the over-speed rotor event.
  • minimum pitch angle alteration refers to the least amount of pitch angle alteration required in the pitch angles of the blades 24 to prevent the rotor 18 from experiencing the over-speed rotor event.
  • the pitch commands are generated based at least in part on inertia of the rotor 18, the available counter-torque margin of the torque control device, a maximum available counter-torque of the torque control device, a maximum allowable rotor speed, or combinations thereof.
  • M Z is aerodynamic torque
  • ⁇ M Z / ⁇ is an aerodynamic sensitivity and a change in aerodynamic torque with respect to unit change in rotor speed
  • ⁇ M Z / ⁇ is another aerodynamic sensitivity and a change in aerodynamic torque with respect to unit change in pitch angle
  • ⁇ 0 is current rotor speed
  • ⁇ max is maximum allowable rotor speed of the rotor 18
  • ⁇ 0 is current rotor acceleration
  • Q g max is maximum available counter-torque
  • Q g 0 is current counter-torque.
  • the equation (4) is determined based upon an assumption or a determination that torque control devices (such as electrical generator 26) are capable of reaching the available counter-torque margin by the over-speeding time T.
  • equation (4) is derived using the analytical transfer function shown in equation (3).
  • the pitch commands are designed to change the pitch angles of the blades 24 to achieve the minimum pitch angle alteration resulting in slow down of the rotor 18 before the occurrence of the over-speed event.
  • Fig. 4 is a flow chart illustrating a method 400 to predict an over-speeding time T, in accordance with one embodiment of the present disclosure such as represented by block 306 of Fig. 3 , for example.
  • Reference numeral 402 is representative of first order differential equation governing rotor speed of the rotor 18.
  • the first order differential equation 402, for example, may be the equation (3).
  • the first order differential equation 402, such as the equation (3) is true for any time interval.
  • the first order differential equation 402 may be applied between a current time 0 seconds and a future time t seconds.
  • the first order differential equation 402 may be solved at any future time, if variations in wind speed, counter-torque of the electrical generator 26 and pitch angle of the blades 24 are known.
  • Reference numeral 404 is representative of an input preview time T'.
  • the input preview time T' may be a commanded time input by a user, for example. In one embodiment, the input preview time T' occurs later in time than the over-speeding time T
  • a future rotor speed at the input preview time T' may be predicted by solving the first order differential equation 402 governing the rotor 18, such as the equation (3), with one or more assumptions.
  • the assumptions may include constant wind speed from the current time till the input preview time T' 404.
  • the wind speed is assumed constant from the current time till the input preview time T', the contribution of the wind speed gets removed from the first order differential equation (3) as the change in wind speed is zero.
  • the future rotor speed at the input preview time T' may be predicted without usage of wind speed data or wind speed related estimations.
  • the constant wind speed assumption makes the over speed control independent of and hence robust to any delay or lag in wind speed estimation.
  • the assumptions may additionally or alternatively include application of available counter-torque margin of the torque control device on the rotor 18.
  • the assumptions may further include application of maximum available counter-torque Q max from current time till the input preview time T'.
  • the assumptions may additionally or alternatively include the pitch angles of the blades 24 being constant, from the current time till the input preview time T'.
  • the over-speeding of the rotor 18 is imminent at the input preview time T'. In other words, it is predicted whether the rotor 18 may over-speed at the input preview time T'.
  • the imminence of the over-speeding of the rotor 18 may be determined by comparing the future rotor speed to a maximum allowable rotor speed ⁇ max of the rotor 18. For example, the rotor 18 may over speed when the future rotor speed is greater than the maximum allowable rotor speed.
  • the over-speeding time T may be determined when the over-speeding of the rotor 18 at the input preview time T' is imminent.
  • the over-speeding time T is the first time from the current time when the rotor speed reaches the maximum allowable rotor speed ⁇ max .
  • the over-speeding time T may be predicted by solving a first order differential equation governed by rotor inertia, such as the equation (3), and an assumption that wind velocity is constant, or a rate of wind speed is constant.
  • the over-speeding time T for example, may be determined using the equation (2).
  • the over-speeding time may be determined based at least in part on an assumption that a rotor speed at the over-speeding time T is equal to the maximum allowable rotor speed.
  • the over-speeding time T may be predicted based at least in part on a plurality of input variable parameters comprising the available counter-torque margin of the electrical generator 26 of the wind turbine 10, and a current counter-torque of the electrical generator.
  • the over-speeding time T may be predicted based at least in part on the maximum allowable rotor speed, the maximum available counter-torque of an electrical generator of the wind turbine system, one or more aerodynamic sensitivities, and inertia of the rotor.
  • the aerodynamic sensitivities may include a change in aerodynamic load with respect to a change in torque of the rotor and a change in the aerodynamic load with respect to a change in the pitch angle of the blades 24.
  • Fig. 5 is a flow chart illustrating a method 500 of one example embodiment to generate pitch commands for the pitch angles of the blades 24 ( FIG. 1 ), in accordance with one embodiment of the present disclosure. Therefore, Fig. 5 is executed when the over-speeding time T of the occurrence of the over-speed event is predicted.
  • reference numeral 302 is representative of current rotor speed
  • reference numeral 304 is representative of current rotor acceleration
  • the reference numeral 404 is representative of the input preview time T'.
  • a minimum pitch angle alteration needed to avoid the occurrence of the over-speed event is determined.
  • the minimum pitch angle alteration for example, is determined based at least in part on inertia of the rotor, the available counter-torque margin of the electrical generator 26, a maximum available counter-torque of the electrical generator 26, a maximum allowable rotor speed, or combinations thereof.
  • the minimum pitch angle alteration may be determined based on one or more analytical transfer functions (such as the analytical transfer function shown in equation (3)) that define the dynamics of the wind turbine 10, and one or more aerodynamic sensitivities.
  • the minimum pitch angle alteration may be determined using the equation (4).
  • a rate of change in the pitch angles of the blades 24 to achieve the minimum pitch angle alteration to avoid the occurrence of the over-speed event may be determined.
  • the rate of change in the pitch angles of the blades for example may be determined based upon the minimum pitch angle alteration and the over-speeding time T
  • the minimum pitch angle alteration is compared to a baseline commanded pitch angle alteration, and the rate of change is compared to a baseline commanded pitch rate change.
  • baseline commanded pitch angle alteration refers to those pitch angle alteration commands that are commanded by baseline operating control models or any other suitable control models and/or methods that are used for day-to-day normal operation of the wind turbine 10.
  • baseline commanded pitch rate change refers to those pitch rate change commands that are commanded by baseline operating control models or any other suitable control models and/or methods that are used for day-to-day normal operation of the wind turbine 10.
  • pitch commands are generated to change the pitch angles of the blades 24 equal to the minimum pitch angle alteration required in the pitch angle of the blades 24.
  • pitch commands are generated to change the pitch angles of the blades 24 equal to baseline commanded pitch angle alteration.
  • the pitch commands are generated to change the pitch angles of the blades 24 at the rate of change.
  • the pitch commands are generated to change the pitch angles of the blades 24 at the baseline commanded pitch rate change.
  • the pitch commands may be sent to a pitch control device, such as the variable pitch controller 32 or the actuators 34 (referred to in Fig. 2 ).
  • the variable pitch controller 32 or the actuators 34 may change the pitch angles of the blades 24 as instructed by the pitch commands.
  • the change in the pitch angles of the blades 24 reduces the rotor speed of the rotor 18 before the occurrence of the over-speed rotor event.
  • the same rate of change of pitch angle is applied to each blade 24.
  • different rates of change may be applied if desired so long as the final result is to prevent the occurrence of the over-speed rotor event.

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  • Engineering & Computer Science (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Sustainable Development (AREA)
  • Sustainable Energy (AREA)
  • Chemical & Material Sciences (AREA)
  • Combustion & Propulsion (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Physics & Mathematics (AREA)
  • Fluid Mechanics (AREA)
  • Wind Motors (AREA)

Claims (13)

  1. Système d'éolienne (10) comprenant :
    une tour d'éolienne (14) ;
    une pluralité de pales (24) ;
    un rotor (22) supporté par la tour (14) et couplé à rotation à la pluralité de pales (24) ;
    un dispositif de commande de couple couplé au rotor ; et
    un système de commande (28) programmé pour prédire un temps de surrégime T d'une occurrence d'un événement de rotor en surrégime sur la base au moins en partie d'une accélération courante du rotor et d'une vitesse courante du rotor qui ne peuvent être compensées par une marge de contre-couple disponible du dispositif de commande de couple et, en réponse, générer des commandes de pas pour les angles de pas de la pluralité de pales (24) afin d'éviter l'événement de rotor en surrégime ;
    caractérisé par les caractéristiques suivantes :
    le système de commande (28) est programmé pour prédire le temps de surrégime T de l'occurrence de l'événement de rotor en surrégime :
    en prédisant une vitesse de rotor future à un moment commandé saisi par un utilisateur T' ;
    en prédisant si le rotor sera ou non en surrégime au moment saisi T' en comparant la vitesse future du rotor à une vitesse maximale autorisée du rotor ; et,
    lorsque le rotor est déterminé comme étant en surrégime au moment saisi T', en déterminant le moment de surrégime T sur la base au moins en partie d'une hypothèse qu'une vitesse du rotor au moment de surrégime T est égale à une vitesse maximale autorisée du rotor.
  2. Système d'éolienne (10) selon la revendication 1, dans lequel le système de commande (28) est programmé pour prédire le moment de surrégime T de l'occurrence de l'événement de rotor en surrégime sans utilisation de données de vitesse du vent ou d'estimations rapportées à la vitesse du vent.
  3. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le moment saisi T' est ultérieur au moment de surrégime T.
  4. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel les commandes de pas sont basées au moins en partie sur une détermination d'une modification d'angle de pas minimale nécessaire pour éviter l'événement de rotor en surrégime.
  5. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le système de commande (28) est en outre programmé pour, lors de la génération des commandes de pas, déterminer un taux de changement des angles de pas de la pluralité de pales afin d'obtenir la modification d'angle de pas minimale pour éviter l'événement de rotor en surrégime au moment de surrégime T.
  6. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le système de commande (28) est programmé pour déterminer le taux de changement des angles de pas de la pluralité de pales sur la base de la modification d'angle de pas minimale et du moment de surrégime T.
  7. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le système de commande (28) est programmé pour générer les commandes de pas sur la base au moins en partie d'une ou plusieurs fonctions de transfert analytiques qui définissent la dynamique du système d'éolienne et d'une ou plusieurs sensibilités aérodynamiques.
  8. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le système de commande (28) est en outre programmé pour générer les commandes de pas sur la base au moins en partie de l'inertie du rotor, de la marge de contre-couple disponible du générateur électrique, d'un contre-couple nominal maximal d'un générateur électrique du système d'éolienne, d'une vitesse du rotor autorisée maximale ou d'une de leurs combinaisons.
  9. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le système de commande (28) est programmé pour prédire le moment de surrégime T de l'occurrence de l'événement de rotor en surrégime sur la base d'une équation différentielle du premier ordre régie par l'inertie du rotor et d'une hypothèse que la vitesse du vent est constante ou que le taux de vitesse du vent est constant.
  10. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le système de commande (28) est programmé pour prédire le moment de surrégime T sur la base au moins en partie d'une pluralité de paramètres d'entrée variables comprenant la marge de contre-couple disponible d'un générateur électrique du système d'éolienne et le contre-couple courant du générateur électrique.
  11. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel le système de commande (28) est programmé pour prédire le moment de surrégime T sur la base au moins en partie d'une vitesse autorisée maximale du rotor, d'un contre-couple disponible maximal d'un générateur électrique du système d'éolienne, d'une ou plusieurs sensibilités aérodynamiques et d'une inertie du rotor (22).
  12. Système d'éolienne (10) selon l'une quelconque des revendications précédentes, dans lequel les une ou plusieurs sensibilités aérodynamiques comprennent un changement de charge aérodynamique par rapport à un changement de couple du rotor (22) et un changement de la charge aérodynamique par rapport à un changement de l'angle de pas de la pluralité de pales (24).
  13. Procédé (400) de fonctionnement d'une éolienne (10), comprenant la prédiction (406) d'un moment de surrégime T d'une occurrence d'un événement de rotor en surrégime de l'éolienne sur la base au moins en partie d'une accélération courante du rotor (22) et d'une vitesse courante du rotor, qui ne peuvent être compensées par une marge de contre-couple disponible du dispositif de commande de couple et, en réponse, la génération de commandes de pas pour les angles de pas de la pluralité de pales (24) pour éviter l'événement de rotor en surrégime ;
    dans lequel la prédiction du moment de surrégime T de l'occurrence de l'événement de rotor en surrégime comprend :
    la prédiction (406) d'une vitesse future du rotor à un moment commandé saisi par un utilisateur T' sur la base au moins en partie d'une hypothèse que le générateur électrique est capable d'appliquer la marge de contre-couple disponible au moment saisi T' ;
    la prédiction du fait que le rotor (22) sera ou non en surrégime au moment saisi T' en comparant la vitesse future du rotor à une vitesse maximale autorisée du rotor ; et,
    lorsque le rotor (22) est prédit pour passer au-dessus de la vitesse au moment saisi T', la détermination du moment de surrégime T sur la base au moins en partie d'une hypothèse qu'une vitesse du rotor au moment de surrégime T est égale à une vitesse maximale autorisée du rotor.
EP15171870.7A 2014-06-30 2015-06-12 Procédés et systèmes pour faire fonctionner un système de turbine éolienne Active EP2963284B1 (fr)

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